Intelligent electronic device with broad-range high accuracy

ABSTRACT

A method and apparatus provides high-accuracy measurements of an electrical parameter across a broad range of parameter input values. In one embodiment, an intelligent electronic device (IED), e.g., a digital electrical power and energy meter, with a plurality of independently-adjustable gain factors measures a parameter, and calculates and stores calibration factors associated with known values of the measured parameter. The IED or meter applies the stored calibration factors when measuring unknown values of the measured parameter, to improve the accuracy of the measurement.

CROSS-REFERENCE TO RELATED PATENT APPLICATIONS

This application also claims priority to U.S. Provisional PatentApplication No. 60/920,198, filed on Mar. 27, 2007, which is hereinincorporated by reference.

FIELD

This patent relates generally to the field of intelligent electronicdevices for electrical utility services and, more specifically, todigital electrical power and energy meters for the electrical utilityservices.

BACKGROUND

Producers, suppliers, and consumers of electrical power rely on energymeters to monitor power consumption and quality for numerous purposes,including billing and revenue calculations, power distributionmanagement, and process management. Traditionally, the primary means ofmeasuring power consumption was an electro-mechanical power meter. Anumber of other types of meters and equipment measured other parametersof power generation, distribution, usage, and quality. As technology hasimproved, intelligent electronic devices (IEDs), such as digital powerand energy meters, Programmable Logic Controllers (PLCs),electronically-controlled Remote Terminal Units (RTUs), protectiverelays, fault recorders, and the like, have slowly replaced theirelectro-mechanical and analog counterparts. The shift to IEDs fromanalog and electro-mechanical devices provides a vast array ofadvantages, including improvements in measurement accuracy (e.g.,voltage, current, power consumption, power quality, etc.) and systemcontrol (e.g., allowing a meter to trip a relay or circuit breaker).

The voltages, currents, and frequencies employed in the variouselectrical systems that utilize IEDs vary widely from region to region(e.g., the United States and Europe), from application to application(e.g., industrial or residential), and across various parts of a powerdistribution system (e.g., generation, transmission, delivery, etc.).For example, power may be generated at one voltage (e.g., 30,000 V), buttransmitted at another, much higher voltage (e.g., 10,000 V), tominimize heat-related power losses related to large electrical currentin the transmission lines. Additionally, a series of power sub-stationstransforms the voltages employed for transmitting power, to bring thevoltage down to the level at which it is distributed to customers (e.g.,220 V). Industrial power consumers in one region may receive power atone voltage (e.g., 480 V), while residential consumers in the sameregion receive power at a second voltage (e.g., 120 V). Residentialconsumers in one region may receive power at one voltage and frequency(e.g., 120 V at 60 Hz in the United States) while similar consumers inanother region may receive power at a different voltage and frequency(e.g., 230 V at 50 Hz in Europe).

Power measurements typically occur at a few industry-standard voltagesand frequencies. Higher operating voltages and currents are reduced to afew standard current ranges, so that the higher operating voltages andcurrents can be measured by meters designed to measure within thosevoltage and current ranges (e.g., 120 V, 208 V, 220 V, 277 V, 347 V, and690 V). However, the disparity in the voltages, currents, andfrequencies employed, not withstanding the relatively few standardranges in which measurements are taken, generally necessitates thatdifferent IEDs be purchased for different input ranges, in order tocomply with the various standards which the IEDs must meet. For example,a digital power and energy meter designed to measure power consumptionand quality at an industrial facility may be inoperable orinaccurate—failing to meet industry requirements for the particularapplication—if employed at a power generation facility.

Thus, to comply with the requirements for accuracy among the multiplestandards adhered to across industries and geographical regions,manufacturers of IEDs commonly configure and sell multiple “options” foreach model of meter, where each of the options includes a voltage andcurrent level that the purchaser expects the meter to measure. Themeters are thereafter calibrated to meet the required standards. Forexample, one standard requires that energy calculations be accurate towithin 0.2%. While many meters are calibrated to achieve an error of nomore than 0.2% for one range of input signal levels (e.g., 120 V or 69V), measuring a different range of signal levels requires recalibrationto achieve the desired accuracy. This requirement is often necessarybecause part-to-part variations in the meter design, and offsets and/orphase shifts in sensor and/or input networks, have varying effects atdifferent signal levels.

SUMMARY OF THE DISCLOSURE

An intelligent electronic device (IED), e.g., a digital electrical powerand energy meter, described herein is operable and highly accurate whileconducting measurement activities at each of a number of differentindustry-standard voltage, current, and frequency ranges. Specifically,the meter includes a plurality of individually-adjustablegain-controlled channels, which selectively regulate the amplitudes ofthe signals communicated to various modules of the meter. The regulatedsignals, which are proportional to the sensed supply voltages and supplycurrents of the electrical service to which the meter is connected, maybe adjusted to match pre-determined ranges for input signals of thevarious modules of the meter, so as to optimally utilize the dynamicrange of the included analog-to-digital converters. In addition, theprocessing module of the meter may be designed to perform a series ofvoltage and/or current calibration measurements, using known voltage andcurrent sources to determine a plurality of calibration factors for usewhile measuring and/or monitoring the electrical service. The meterutilizes these calibration factors to achieve optimal accuracy whenmeasuring within each of the ranges of voltage and current in which themeter may operate. The calibration measurements may further includeperforming each series of calibration measurements at multiplefrequencies, to achieve optimal accuracy regardless of the frequencyrange of the monitored signal.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 depicts an exemplary electrical power distribution grid fortransmitting electrical power from a power plant to a plurality ofconsumers and employing a plurality of digital electrical power andenergy meters.

FIG. 2 is a block diagram illustrating an exemplary digital electricalpower and energy meter.

FIG. 3 is a block diagram illustrating a metering module of theexemplary meter of FIG. 2.

FIG. 4 is a block diagram illustrating a processing module of theexemplary meter of FIG. 2.

FIG. 5 depicts the various contents of the memory module of FIG. 4.

FIGS. 6A & 6B illustrate alternative methods for calibrating a digitalelectrical power and energy meter.

FIGS. 7A & 7B illustrate sample sets of calibration measurements andcalibration factors corresponding to the methods of FIGS. 6A & 6B,respectively.

FIG. 8 illustrates a method for applying a set of calibration factors toa plurality of measurements.

FIGS. 9A and 9B depict two alternate methods for using interpolation toachieve accurate measurements.

To facilitate understanding, identical reference numerals have beenused, where possible, to designate identical elements that are common tothe figures, except that suffixes may be added, when appropriate, todifferentiate such elements.

The appended drawings illustrate exemplary embodiments of the presentdisclosure and, as such, should not be considered as limiting the scopeof the disclosure that may admit to other equally effective embodiments.It is contemplated that features or steps of one embodiment maybeneficially be incorporated in other embodiments without furtherrecitation.

DETAILED DESCRIPTION

FIG. 1 depicts an electrical power distribution grid 10 including anumber of electrical service environments which may employ digitalelectrical power and energy meters, such as those disclosed herein. Apower plant 12 includes a plurality of generators 14 powered by steam,coal, natural gas, nuclear reactor, etc. Each of a plurality of digitalelectrical power and energy meters 16 monitors various parameters (e.g.,voltage, current, frequency, power quality, etc.) of the output of thegenerators 14.

As illustrated in FIG. 1, the generators 14 transmit the generatedenergy from the power plant 12 to a distribution substation 18. At thedistribution substation 18, one or more step-up transformers 20transform the energy generated by the generators 14 from a relativelylower voltage (e.g., 10,000 V) generated by the generators 14 to arelatively higher voltage (e.g., 500,000 V) for transmission over longdistances using high-voltage transmission lines 24. A plurality ofdigital electrical power and energy meters 22 may monitor the energy ateither or both of the inputs and the outputs of the step-up transformers20 to, for example, verify that proper voltages, frequencies, and phaserelationships are maintained, and generally to monitor the overallhealth of the distribution grid 10.

A bulk power substation 26 receives the energy transmitted over thehigh-voltage transmission lines 24 from the distribution substation 18.One or more step-down transformers 28 in the bulk power substation 26transform the energy received over the high-voltage transmission lines24 from the transmission voltage to a relatively lower voltage (e.g.,100,000 V). The bulk power substation 26 also includes on or more buses(not shown) to allow the energy to be directed in different directionsfor transmission to multiple locations. Of course, the bulk powersubstation 26 may employ a plurality of digital electrical power andenergy meters 30 to monitor the energy at the substation 26, just as themeters 16, 22 monitor energy at the power plant 12 and the distributionsubstation 18.

The bulk power substation 26 transmits the energy output from thestep-down transformers 28 to one or more distribution substations 32.Each of the distribution substations 32 includes one or more step-downtransformers 34 for further transforming the energy to a relativelylower voltage (e.g., 7,200 V) for distribution to consumers, and mayalso include a plurality of digital electrical power and energy meters36 for further monitoring of power parameters. The distributionsubstations 32 transmit the energy via local power lines 38 to variousdistribution transformers 40. The distribution transformers 40 step-downthe voltage once more to the distribution voltage (e.g., 240 V or 480V). From the distribution transformers 40, the energy is transmitted toresidential consumer facilities 42 (e.g., homes) and industrialconsumers facilities 44 (e.g., factories).

Industrial consumer facilities 44, in particular, may employ a pluralityof digital electrical power and energy meters 46, 48, 50, 52 throughoutthe industrial environment. For example, the meter 46 may monitor theenergy coming from the utility, as a means of verifying that the utilityis providing power of sufficient quality (i.e., relatively free of sagsand swells, having low harmonic distortion, etc.) and not overchargingthe industrial consumer for more power than the utility actuallydelivers. Of course, the utility may also monitor the energy and qualitydelivered, using the meter 46. The meter 48 may be used, for example, tomonitor energy consumption by, and the quality of power delivered to,one or more loads 54 within the industrial consumer facility 44.Similarly, the meters 50 and 52 may monitor other parts of theindustrial consumer facility, such as back-up generation capacity 56(e.g., generators) and other loads 58 connected to the back-upgeneration capacity 56. In this manner, the electrical power and energymeters 16, 22, 30, 36, 46, 48, 50, and 52 may monitor energy creation,distribution, and consumption throughout the distribution grid.

FIG. 2 depicts a block diagram illustrating an exemplary digitalelectrical power and energy meter 100 which may be used to implement anyof the electrical power and energy meters 16, 22, 30, 36, 46, 48, 50,and 52 of FIG. 1. The meter 100 generally comprises a metering module110 for measuring or calculating one or more parameters associated withthe electrical load or service (e.g., voltage, current, energy, etc.)and a processing module 120 for facilitating operation of the meter 100and processing data obtained from the metering module 110. The meter 100may also include a user interface unit 130 for displaying results ofmeasurements and calculations and allowing configuration of the meter100; one or more input/output (I/O) modules 135, for facilitatingcommunication of data to an external device (not shown); acommunications module 140 for coupling to one or more remote terminals(not shown); and a power supply 150 for providing power to the variouscomponents and modules of the meter 100. Said (I/O) modules include butare not limited to transducer outputs consisting of DC signals output bya digital to analog converter which are proportional to the desiredmeasured parameters in exemplary ranges such as −1 to 0 to +1 mAoutputs, 0 to 1 mA outputs, 4-20 mA outputs or others wherein the usergenerally can program the low scale and high scale parameter for theoutput. Other input/output modules include Ethernet, Profibus, LonWorks, telephone modem, wireless transceiver, cellular modem or phone,relay outputs, pulse outputs, analog inputs and status inputs, etc. Anyone or more of these types of input/output modules are consideredfacilitating communication of data to an external network.

During normal operation, the metering module 110 may be coupled to anelectrical service to be measured and/or monitored, such as thethree-phase electrical service 101 of FIG. 2. A current interface 107and a voltage interface 109 couple the meter 100 to supply lines 103 A,B, C, and N of the electrical service 101. Alternatively, whencalibrating the meter 100, the current interface 107 and the voltageinterface 109 may couple the metering module 110 to a calibrationreference 102. Manufacturers typically perform meter calibrationsubsequent to assembly of the meter 100 and prior to shipping the meter100 to the intended customer. Calibration may also be performed atperiodic intervals thereafter over the lifetime of the meter 100. Eachof the interfaces 107 and 109 may include a plurality of connections(indicated in FIG. 2 by the bold connecting arrows), e.g., connectionsto each of phases A, B, C, and N, in the depicted embodiment. U.S.patent application Ser. No. 11/003,064, now U.S. Pat. No. 7,271,996,details some methods of coupling digital electrical power and energymeters to various electrical services. The connections of the interfaces107, 109 may be, for example, screw-type connections, blade-jawconnections, etc. Those of ordinary skill in the art will be familiarwith other methods for coupling meters to electrical services, thusthese methods need not be described further herein.

The metering module 110 may include a sensing module 115 for sensing thecurrents and voltages on the interfaces 107 and 109, respectively, andgenerating for each sensed current or voltage, a signal representativethereof. The sensing module 115 includes voltage sensing circuitry 117connected to the voltage interface 109, and current sensing circuitry119 connected to the current interface 107. In the depicted embodiment,the metering module 110 also includes a metering processor 118, forcalculating one or more parameters of the electrical service 101. Inparticular, the metering processor 118 of the current embodiment maycalculate energy usage.

An interface 123, which communicatively couples the metering module 110to the processing module 120, may include one or more buses connecting,for example, the metering processor 118 and the sensing module 115 tothe processing module 120. In one embodiment, the interface 123 includestwo analog signal paths from the sensing module 115 to a processor 160,and digital data paths (e.g., address and data buses, a serialperipheral interface, etc.) between the metering processor 118 and theprocessor 160. The analog signal paths include additional analogchannels for use by the processor 160, as described in detail below.Interfaces 133 and 143 communicatively couple the processing module 120to the user interface module 130 and the communications and/or I/Omodules 135 and 140, respectively. The interfaces 123, 133, 143 may beany type of physical interfaces, and may be any appropriate logicalinterfaces. For example, where each module resides on a separate printedcircuit board (PCB), each physical interface may include a cable, aheader/receptacle connector, a card-edge connector, or a stackableconnector. Each logical interface may include a serial interface orserial peripheral interface (SPI), one or more parallel data/addressbuses, etc. Said interfaces could be using an electrical or opticalmeans. Further, multiple modules may reside on a single PCB, allowingthe modules to be connected via connections embedded in the PCB.Additionally, the modules need not be physically distinct from oneanother, nor need the modules be physically segregated.

In the embodiment depicted in FIG. 2, the processing module 120, whichmay be disposed on one PCB or on multiple PCBs, includes the processor160 (e.g., a micro-processor, a digital signal processor (DSP), etc.)and a memory module 180 having one or more computer-readable storagedevices (e.g., memories). For example, the memory module 180 may includean electrically erasable programmable read-only memory (EEPROM) 182, aflash memory 184, and/or a random access memory (RAM) 186. An interface178, which connects the processor 160 to the memory module 180, may beany known interface compatible with the particular memory devices 182,184, 186 and with the particular processor 160. The processing module120 may also include additional elements, such as a real-time clock 196,a backup power source (e.g., a battery) 194, and various other supportcircuitry 192. It is envisioned as part of the present disclosure thatthe processing module 120 may incorporate all elements such as processor160 and memories 180 or any other peripheral via on-board chipconnections in which the functions are included as part of a singlesemi-conductor device. It is also envisioned that these modules can belocated in separate devices and in a combination of on-board andseparate devices.

Referring now to FIG. 3, the voltage sensing circuitry 117 in thesensing module 115 may include three voltage dividers or potential (orvoltage) transformers (i.e., one for each of electrical phases A, B, andC) 117A, 117B, 117C for proportionally decreasing the voltage sensed bythe metering module 110. The current sensing circuitry 119 may includethree conductors (i.e., one for each of electrical phases A, B, and C),each passing through a toroidal coil 119A, 119B, 119C, a currenttransformer or some other type of current sensing device such as currentshunts, rogowski coil, etc. The voltage sensing circuitry 117 and thecurrent sensing circuitry 119 generate signals representative of thethree voltages phases and the three current phases, respectively.

The plurality of signals representative of the voltage and current arecommunicated from the sensing module 115 to the metering processor 118via, for example, interfaces 121V and 121I. The interfaces 121 may beany suitable interfaces, including, if the sensing module 115 and themetering processor 118 are on a single PCB, traces embedded in the PCB.In one embodiment, the signals representative of the voltage and currentare received by the metering processor 118. The metering processor 118includes circuitry 112A, 112B, 112C, 114A, 114B, 114C for converting theanalog signals representative of the sensed currents and voltages todigital signals (e.g., using analog-to-digital converters (ADCs)), andcircuitry 111A, 111B, 111C, 113A, 113B, 113C for applying a gain factorto the signals to effectively utilize the full resolution of the ADCs.Of course, the ADCs 112A, 112B, 112C, 114A, 114B, 114C and/or the gaincircuitry 111A, 111B, 111C, 113A, 113B, 113C, may be discrete componentsand need not be included within the metering processor 118. While themetering processor 118 illustrated in FIG. 3 includes three current ADCs112A, 112B, 112C and three voltage ADCs 114A, 114B, 114C (e.g., one ADCfor each of the sensed signals), fewer ADCs may be used if employed incombination with a plurality of sample-and-hold registers andmultiplexers. In such an application, one ADC may convert the voltagevalues and one ADC may convert the current values. Of course, the ADCsmust operate fast enough to perform all three (or six) conversionsbefore the sample time has elapsed. For example, if two ADCs areemployed (one each for voltage and current), and if each phase is to besampled 10 times per second (or every 100 ms), each ADC must be capableof performing at least 30 analog-to-digital conversions each second (oneevery 100 ms for each of the three phases).

Each gain circuit 111A, 111B, 111C, 113A, 113B, 113C may include one ormore gain-controlled amplifiers. Each gain-controlled amplifier mayselectively amplify a single output signal of the sensing circuit (i.e.,an input signal of the gain circuit), according to a corresponding gainfactor. The processing module 120 may program the gain factor for eachof the gain circuits 111A, 111B, 111C and 113A, 113B, 113C, for example,by setting a register (not shown) in the metering processor 118 throughthe interface 123. The gain factor for each of the amplifiers in thegain circuits 111A, 111B, 111C, 113A, 113B, 113C may be selected from aplurality of gain factors prior to measuring the output of the sensingcircuit 117, 119, such as by selection via the user-interface 130 when auser knows the appropriate gain factor for the electrical service 101 towhich the meter 100 is connected. Alternatively, the gain factor foreach of the amplifiers in the gain circuits 111A, 111B, 111C, 113A,113B, 113C may be selected in response to measuring the output of thesensing circuitry 117, 119, allowing the meter 100 to adjust the gainfactors automatically and without user intervention and thereby allowingthe meter 100 to operate on any electrical service to which it isconnected. It should be recognized that the gain factors selected foreach of the gain-controlled amplifiers need not be the same. Moreover,the plurality of gain factors available for the gain-controlledamplifiers of the current gain circuit 111A, 111B, 111C, need not be thesame as those available in the voltage gain circuit 113A, 113B, 113C.

A measurement parameter calculation routine 116 running on the meteringprocessor 118 uses the digital outputs of the ADCs 112A, 112B, 112C,114A, 114B, 114C to determine the power or energy on each phase (i.e.,by multiplying the current by the voltage). The metering processor 118communicates the results of the energy calculations across the interface123 to the processing module 120. Of course, the gain circuitry 111A,111B, 111C, 113A, 113B, 113C, the ADCs 112A, 112B, 112C, 114A, 114B,114C, and the energy calculation routine need not be in a single chipsuch as in the metering processor 118. For example, the current gaincircuitry 111A, 111B, 111C and the voltage gain circuitry 113A, 113B,113C may each be a multi-channel variable gain amplifier, while thecurrent ADCs 112A, 112B, 112C and the voltage ADCs 114A, 114B, 114C mayeach be a multi-channel ADC package. In such an implementation, thepower or energy calculation may be implemented on a specialized meteringchip or a stand-alone DSP.

Referring now to FIG. 4, the memory module 180 may store data related tothe operation of the meter 100 in a plurality of areas 180A of thememory module 180. These data may include operating parameters data 183such as the settings of the device (e.g., alarm triggers, communicationconfigurations, data formats, etc.); measured parameter data 181 such asharmonic information and Fourier transforms; waveform data 189; power orenergy calculation data 188; various log data 187 of power qualityevents (e.g., sags, swells, transients, etc.); a plurality of routines185 necessary to operate the meter 100 (e.g., gain control routines,waveform capture routines, calibration routines, etc.); and calibrationdata and/or tables 190. As used herein, the term “calibration data”refers to calibration factors, and is used interchangeably as such. Asdescribed below, the calibration factors may be offset data (“offsetcalibration factors”) or linear slope data (“linear calibrationfactors”) or other types of calibration factors. The data stored withinthe memory module 180 may be stored in the memory module 180 in anymanner known by those of ordinary skill in the art. Moreover, these dataneed not be stored in a single device (such as the EEPROM 182, the flashmemory 184 or the RAM 186). For example, the routines 185 andcalibration data 190 may be stored in the EEPROM 182, the log data 187stored in the flash memory 184, and the remainder of data stored in theRAM 186.

One or more buses 178 communicatively connect the memory module 180 tothe processor 160, depending on the processor and memory devicesemployed. As shown in FIG. 4, the processor 160 may also serve tocommunicatively couple the memory module 180 to the other modules, suchas to the metering module 110 (e.g., by the buses 178 and 123). Thisconnection may be necessary, for example, to facilitate storage ofenergy measurements, to implement gain control in the metering module110, or to facilitate storage or retrieval of calibration data, as willbe discussed in detail below.

The processor 160 runs or executes the routines 185 stored in the memorymodule 180, and generally performs calculations and otherwisemanipulates data, in addition to administering operation of the meter100. The routines 185 may include, by way of example and not limitation,an FFT routine 162, a gain control routine 164, a waveform captureroutine 168, a calibration routine 170, I/O & communication routines172, and administration routines 174.

In addition to the routines 185 described above for administeringoperation of the meter 100 and processing data obtained using themetering module 110, the processing module 120 may additionally executeone or more routines for implementing virtual relay logic functionality.Virtual relay logic functionality allows a user to configure the meter100 to monitor one or more parameters, and to detect when a numericalvalue of the parameter meets or exceeds a pre-determined threshold. Thepre-determined threshold may be programmed by the user directly or via aremote terminal (i.e., sending threshold settings to the processingmodule 120 via the communication module 140), and may include, forexample, a minimum value or a maximum value for the parameter. Theparameter monitored in the virtual relay may be any parameter measuredby the meter 100, including actual or root mean square (RMS) values of aline voltage, a line current, a phase voltage, a phase current, or atotal harmonic distortion, or may be energy, revenue, real power,reactive power, total power, or a power factor. When an “event” isdetected, the processing module 120 may be configured to record thesettings, timing, and values associated with the event, or to transmitthe information pertaining to the event to a remote terminal, fordisplay or storage on the remote terminal. Moreover, informationpertaining to events may also be reported or signaled to a deviceexternal to the meter 100 by changing a state of a relay contact or asolid state contact, changing a state of a digital output on one of theI/O cards, or changing a numerical value of an analog signal. Inaddition to logic checking, virtual relay logic also allows users to addadditional parameters as defined in the programming section to includeparameters like and/or/nand/nor or any other desired logical descriptor.Moreover, the logic could further be used to obtain custom calculationssuch as conversion from Watts to horsepower or to determine BTUs or theconvert energy usage to dollar cost, etc. Moreover, the logic mayincorporate complex instructions like to run specific executable codeupon event or to allow users to custom program and configure the meter(or IED) using code or programming to add new functionality notenvisioned by the developer.

Additionally, the processor 160, may include circuitry 163 and 165 forimplementing gain control on the additional voltage and current signalchannels coming from the sensing module 115 as part of the interface 123and converting the analog signals representative of the sensed currentsand voltages to digital signals (e.g, using one or more ADCs). Theprocessor 160 may use the additional channels, each of which includes avoltage signal and a current signal for each phase of the electricalservice 101, and the corresponding circuitry 163 and 165 for meteringtasks that require different gain factors than the gain factors used inthe energy metering functions executed on the metering module 110 tofully utilize the dynamic range of the corresponding ADC. In particular,the processor 160 may use one of the additional signal channels toprovide waveform capture functionality. In contrast to calculatingenergy consumption (or generation), waveform capture typically requiresa much larger dynamic range to capture transients such as voltage spikes(which may exceed the nominal voltage of the system by orders ofmagnitude). The processor 160 may use another additional voltage signalchannel and current signal channel for calculating harmonic effects inthe electrical service, as capturing this information may require yet adifferent dynamic range, and thus a different gain setting.

While a single processor 160 is illustrated in the embodiment depictedin FIGS. 2 and 4, the processor 160 may be one or more processors (e.g.,two micro-processors, a micro-processor and a DSP, etc.). Likewise,while FIG. 4 depicts the gain and ADC circuitry 163 and 165 as disposedwithin the processor 160, these components may be implemented separatelyfrom the processor 160 in any known manner, such as those describedabove with reference to the circuitry in the metering processor 118.

The following paragraphs describe the calibration features of the meter100. As described above, the processor 160 runs the plurality ofroutines 185, which include one or more calibration routines 170. Withreference now to FIG. 5, the calibration routines 170 may include, forexample, a routine 200 for determining and storing one or morecalibration factors, which calibration factors are indicative of theerror between the actual value of a measured parameter and the measuredvalue of the parameter. The routine 200 may calculate and store the oneor more calibration factors for each desired calibration range in whichthe meter is to operate. The calibration routines 170 may also include aroutine 300 for using the stored calibration factors determined by theroutine 200 such that the measurement data reported or recorded by themeter 100 represents the actual value of the measured parameter. Thecalibration routines 170, examples of which are described in more detailbelow, may also optionally include a routine 400 for interpolatingstored calibration factors to determine additional calibration factorsas described below. The meter 100 may implement each of the calibrationroutines 170 using multiple different methods, and each method may useone of several types of calibration factors. Some of these methods willbe described below.

FIG. 6A depicts a flow chart describing a method 201, corresponding tothe routine 200, for determining one or more calibration factorscorresponding to a measured parameter in the IED. In a first step 202,the meter 100 is connected, via the interface 107 or 109 to a referencecurrent and/or voltage source, respectively, such as to the calibrationreference 102, depicted in FIG. 2. The calibration reference 102provides a known current and/or voltage signal, at a known (and usuallyselectable) amplitude, to allow a comparison between the actual value ofthe parameter being calibrated and the value of the parameter asmeasured by the meter 100. In a step 204, the calibration reference 102is set to provide a known signal amplitude in the calibration range. Forexample, to calibrate the voltage measurements of the meter 100 in the277 V calibration range (which range has a full-scale value of 500 V,thereby giving it a range of 0 V to 500 V, inclusive), the calibrationreference 102 may first be set to 20.000 V. In a step 206, the value ofthe signal as measured by the meter 100 is determined. In a step 208,the measured value is compared to the actual value (i.e., the referencevalue). Using the measured and actual values of the parameter (e.g., thevoltage), step 210 determines a calibration factor. Of course, thecalibration factor may be, for instance, an offset calibration factor(i.e., a value that should be added or subtracted from the measuredvalue of the parameter to determine the actual value of the parameter),a linear calibration factor (i.e., a value that should be multipliedwith the measured value of the parameter to determine the actual valueof the parameter), or some combination of offset and linear calibrationfactors. Alternatively, the calibration factor may be determinedaccording to calculations of average values or some other statisticalmethod. Moreover, an offset calibration factor may be a fixed offset ora variable offset, which variable offset varies according to somepredetermined formula or criteria. At a step 212, the determinedcalibration factor is stored in the memory module 180 (preferably in anon-volatile memory such as the EEPROM 182 in FIG. 2) and, inparticular, the calibration factor may be stored as associated with themeasured value of the parameter.

FIG. 6B depicts a flow chart describing an alternative method 221 forcalibrating a measured parameter in the IED. In a first step 222 themeter 100 is connected, via the interface 107 or 109 to a referencecurrent source and/or a reference voltage source, respectively, such asto the calibration reference 102, depicted in FIG. 2. In a step 224, thecalibration reference 102 is adjusted until the signal amplitudeprovided by the calibration reference 102 causes the meter 100 tomeasure a desired value in the calibration range. For example, tocalibrate the voltage measurements of the meter 100 in the 277 Vcalibration range, the calibration reference 102 may be adjusted untilthe value measured by the meter 100 is 20.000 V. This may correspond toan actual value (i.e., the value provided by the calibration reference102) of 19.802 V. At a step 226, the measured value is compared to theactual value (i.e., the reference value). A step 228 then uses themeasured and actual values of the parameter (e.g., the voltage) todetermine a calibration factor. As described above, the calibrationfactor may be an offset calibration factor, a linear calibration factor,or any other type of calibration factor. At a step 230, the determinedcalibration factor is stored in the memory module 180.

In either of the methods 201 and 221, the calibration factor may bedetermined using known methods. For example, a linear calibration factor(wherein multiplication of a measured value of a parameter by thecalibration factor converts the measured value of the parameter to theactual value of the parameter), may be determined by dividing thereference value (i.e., the actual value of the parameter) by the valueof the parameter as measured. This computation may be expressed as:

$F = \frac{X_{R}}{X_{M}}$where F is the calibration factor, X_(R) is the reference value of theparameter, and X_(M) is the value of the parameter as measured by themeter 100. Likewise, an offset calibration factor (wherein adding thecalibration factor to a measured value of a parameter converts themeasured value of the parameter to the actual value of the parameter),may be determined by finding the difference between the reference valueand the value of the parameter as measured. This calculation may beexpressed as:F=X _(R) −X _(M)

Moreover, the steps 202 to 212 (or the steps 222 to 230) may be repeatedfor each of the values in a particular calibration range. Assuming, forexample, that the calibration range is 277 V, calibration measurementsmay be made (and calibration factors determined) in, for example, 20 Vincrements (e.g., at 20 V, 40 V, 60 V, etc.). In this manner, aplurality of calibration factors may be determined for the 277 V rangeof measurements. It should be noted that the number of measurements in agiven calibration range may be as few as one. For example, in onealternative method for calibrating a range of signals, calibrationmeasurements may be made at the range value (e.g., 277 V) and thefull-scale value for that range (e.g., 500 V), instead of at smallerincrements within the range. Alternatively, the meter 100 may determineone or more calibration factors using averaging or other statisticaltechniques. Moreover, the method 201 (or the method 221) may berepeated, for each of the calibration ranges, at multiple frequencies(e.g., 50 Hz and 60 Hz), to allow the meter 100 to operate with improvedaccuracy regardless of the nominal operating frequency of the electricalsystem 101. The meter 100 may store the determined calibration factor orfactors as an individual value (e.g., where there is a single offsetcalibration factor or linear calibration factor for each calibrationrange) or in a look-up table or other data structure (e.g., wheremultiple offset or linear calibration factors exist for each calibrationrange).

FIGS. 7A and 7B depict an example set of calibration measurements and aset of example linear calibration factors determined from themeasurements that might result from the methods 201 and 221,respectively. As will be seen, the tables 240 and 260 have five columns.A column 242 depicts example values of signals generated by thecalibration reference 102. A column 244 depicts example values of thesignals generated by the calibration reference 102, as measured by themeter 100. A column 246 depicts the calibration factor calculated usingthe values in the columns 242 and 244. Lastly, columns 248 and 250depict the error for the particular example reference value before andafter application of the calibration factor, respectively. For example,the first row in the column 242 of the table 240 shows a reference valueof 20.00 V, while the column 244 of the table 240 indicates that thevalue measured by the meter 100 was 18.76 V. Thus, there is ameasurement error of 6.200% (indicated in the column 248 of the table240). By comparison, after application of the corresponding calibrationfactor as depicted in the column 246 of the table 240, the error is lessthan 0.2% (as depicted in the column 250 of the table 240).

The method 201 shown in FIG. 6A (or the method 221 shown in FIG. 6B) isrepeated for each of the desired calibration ranges (e.g., 69 V, 120 V,277 V, etc.). Thus, subsequent to calibration, the memory module 180 ofthe meter 100 will contain calibration data 190 for each of the desiredcalibration ranges, allowing the meter 100 to operate with the desiredaccuracy (e.g., less than 0.2% error) in any of its intended operatingranges. Of course, the calibrated parameters need not be restricted tovoltage and current. Additional parameters and/or measurements may alsobe calibrated in each of any number of desired calibration ranges. Theseparameters and/or measurements may include, by way of example and notlimitation, RMS current, RMS voltage, phase, apparent power, reactivepower, active power, frequency, etc.

FIG. 8 depicts a method 301, that may be implemented by the routine 300,for using the stored calibration factors determined by the routine 200and stored in the memory module 180 to determine a calibratedmeasurement (i.e., an actual value) of the measured parameter. In a step305, the meter 100 is connected, via the interface 107 or 109 to anelectrical service 101 which operates at a nominal voltage with anominal frequency. Further, the load (not shown) on the electricalservice 101 draws current at some nominal capacity.

At a step 310, the processing module 120 assesses the appropriate gainfor each of the measured current and voltage signals by first assessingthe nominal values of the voltage and current in the electrical system101 (i.e., ignoring the effects of transients, harmonics, etc.). Theprocessing module 120 then determines the industry standard nominalvalue for the voltage (e.g., 69 V, 120 V, 230 V, 277 V, 347 V, 416 V,721 V, etc.) and the industry standard nominal range for the current(e.g., 0-1 A, 0-5 A, or 0-10 A). Next, the processing module 120 selectsthe appropriate voltage gain and the appropriate current gain tooptimally utilize the full resolution of the ADCs 112A, 112B, 112C,114A, 114B, 114C.

Those of ordinary skill in the art will appreciate that gain adjustmentsfor the supply voltages and currents may be performed in a real time(i.e., dynamically) by a gain control routine 164 or, alternatively, thegain factors for the amplifiers 111A, 111B, 111C, 113A, 113B, 113C maybe pre-configured via the user interface 130 based on knowncharacteristics of the electrical service 101 or electrical load, whichpower consumption is monitored using the meter 100. Additionally, thegain control routine 164 may operate within the processor 160 of themetering module 120, as described above and as depicted in FIG. 4, ormay operate within the metering processor 118. Further, the nominalvalues of the voltage and the current in the electrical system 101 maybe determined from the output of the sensing module 115 (i.e., thevoltage sensing circuitry 117 and current sensing circuitry 119) or,alternatively, from the output of the metering processor 118. Thus, inoperation, the step 310 allows the meter 100 to perform measurements ofthe voltages and currents, regardless of their nominal values, with thesame high accuracy in the respective operating ranges of the meter 100.

At a step 315, the meter 100 measures the parameter to which calibrationdata is to be applied. For example, if calibration data exists for RMSvoltage measurements (e.g., as the stored calibration data 190 withinmemory module 180), the meter 100 measures the RMS voltage of theelectrical service 101.

The processing module 120 determines one or more appropriate calibrationfactors in a step 320. The appropriate calibration factors may beselected based on one or more criteria including, for example, theamplitude of measured parameter, the gain factors applied to the currentand/or voltage inputs, and the calibration range in which the meter 100is operating (e.g., if the meter is attached to a 277 V system, thecalibration factors for the 277 V calibration range may be selected).

At a step 325, the meter 100 uses the one or more calibration factorsdetermined in the step 320 to calculate a calibrated measurement (i.e.,an actual value) of the measured value of the parameter. Calculating themeasured value of the parameter to find the actual value of theparameter may require multiplying the measured value by the linearcalibration factor. This action may be expressed mathematically as:X _(A) =X _(M) *Fwhere X_(A) is the actual value of the parameter, X_(M) is the measuredvalue of the parameter, and F is the chosen calibration factor.Alternatively, calculating the measured value of the parameter to findthe actual value of the parameter may require adding the offsetcalibration factor (where offset calibration factors are employedinstead of linear calibration factors) to the measured value of theparameter. This operation may be expressed mathematically as:X _(A) =X _(M) +FThe re-calculated data (i.e., X_(A)) for the parameter is thenselectively stored in the memory module 180, displayed on the userinterface 130, and/or forwarded to a pre-determined addressee (e.g.,another module, a personal computer, etc.) via the I/O module 135 or thecommunications module 140.

FIGS. 9A and 9B depict methods 401 and 451 for determining one or moreadditional calibration factors using interpolation of the previouslydetermined and stored calibration factors. The calibration method 201,described above, results in the calibration factors stored in the memorymodule 180. While application of these calibration factors in accordancewith, for example, routine 300, produces accurate measurements at thecalibration values for which measurements were taken, any measured valuethat falls between two adjacent values for which calibration factorsexist may not be as accurate. For example, if calibration measurementswere made (and corresponding calibration factors determined and stored)at 20 V and 40 V, a measured value between 20 V and 40 V would have nocorresponding calibration factors. While in some circumstances one maybe able to provide the required accuracy (e.g., less than 0.2% error) byapplying calibration factors for one or the other of the two adjacentcalibration measurements, increased accuracy may be provided by usinginterpolation to find a more accurate calibration factor.

The method 401 of FIG. 9A determines one or more additional calibrationdata points using interpolation of the stored calibration data. In afirst step 405, the processing module 120 determines the calibrationrange in which the meter 100 is operating. Calibration factors (F₁ andF₂) for the two measured values (X_(M1) and X_(M2)) of the parameter atwhich adjacent calibration measurements were taken are determined in astep 410. For example, where the measured value (X_(M3)) of theparameter is 30 V, the two measured values (X_(M1) and X_(M2)) adjacentpoints at which calibration measurements were taken may be 20 V and 40V, and the corresponding linear calibration factors (F₁ and F₂) may be1.100 and 1.300, respectively.

At a step 415, the processing module 120 determines the slope b of aline drawn between the linear calibration factors. The slope b of such aline between the linear calibration factors may be determined by theequation:

$b = \frac{\left( {F_{2} - F_{1}} \right)}{\left( {X_{M\; 2} - X_{M\; 1}} \right)}$In the example above, F₁ and F₂ are 1.100 and 1.300, respectively, andX_(M1) and X_(M2) are 20 V and 40 V, respectively. Therefore, b=0.10.

Having found the slope b, the processing module 120 applies the slope tofind the new calibration factor F₃ in a step 420. The calibration factorF₃ may be determined by the equation:F ₃=(X _(M3) −X _(M2))b+F ₂Applying this equation in the example above to find a calibration factorto apply to a measured value of 30 V (i.e., X_(M3)=30 V), it isdetermined that the calibration factor F₃ is 1.200. This new calibrationfactor may be applied to the measured value to find the actual value(X_(A3)) in the same manner as described with reference to the method301 (i.e., X_(A3)=F₃*X_(M3)). Optionally, a step 425 may store the newlydetermined calibration factor for future use with the other calibrationdata 190 in the memory module 180. Alternatively, the step 425 may storeother or additional data, such as the slope b of the line between thecalibration factors.

Interpolation may also be applied to the values of the measured signalsused to calibrate the meter 100, as shown in the method 451 of FIG. 9B.At a first step 455, the processing module 120 determines thecalibration range in which the meter 100 is operating. A step 460 thendetermines the actual values (X_(A1) and X_(A2)) for the two measuredvalues (X_(M1) and X_(M2)) of the parameter at which adjacentcalibration measurements were taken. For example, where the measuredvalue of the parameter (X_(M3)) is 30 V, the two measured values (X_(M1)and X_(M2)) at which adjacent calibration measurements were taken may be20 V and 40 V, and the corresponding actual values (X_(A1) and X_(A2))may be 19.802 V and 38.835 V, respectively. The processing module 120may find the corresponding actual values (X_(A1) and X_(A2)) bycalculating these actual values using the calibration factors (F₁ andF₂) stored in the memory module 180 as associated with the measuredvalues (X_(M1) and X_(M2)). This calculation may be expressed as:

$X_{A\; 1} = \frac{\left( X_{M\; 1} \right)}{\left( F_{1} \right)}$$X_{A\; 2} = \frac{\left( X_{M\; 2} \right)}{\left( F_{2} \right)}$Alternatively, the actual values corresponding to the measured valuescould be stored in addition to, or instead of, the calibration factors,and the actual values may be retrieved directly from the memory module180 instead of being calculated. Of course, both of methods 401 and 451may also be used to determine, by interpolation, additional offsetcalibration factors.

At a step 465, the processing module 120 determines the slope b of theactual values. The slope b of the actual values may be determined by theequation:

$b = \frac{\left( {X_{A\; 2} - X_{A\; 1}} \right)}{\left( {X_{M\; 2} - X_{M\; 1}} \right)}$In the example above, X_(A1) and X_(A2) are 19.802 V and 38.835 V,respectively, and X_(M1) and X_(M2) are 20 V and 40 V, respectively.Therefore, in this example, b=0.001.

Having found the slope b, the processing module 120 uses the slope b tofind the new actual value X_(A3) in a step 470. The actual value X_(A3)may be determined by the equation:X _(A3)=(X _(M3) −X _(M2))b+X _(A2)Applying this equation in the example above to find the actual valueX_(A3) of a measured value of 30 V (i.e., X_(M3)=30 V), it is determinedthat the actual value X_(A3) is 29.319 V. Of course, if desired, a step475 may store this value in the memory module 180 for future use.

The above procedures may also be used to determine, by interpolation,calibration factors (or calibrated measurement values) at frequenciesother than the frequencies at which the meter 100 may be calibrated(e.g., 50 Hz and 60 Hz). The extrapolation process starts withdetermining the two (but not limited to) calibration factors closest tothe range of the measured parameter. The next step is to apply theextrapolation algorithm to determine the approximated calibration factorat the given point where the parameter is measured at. The extrapolationalgorithm calculates the magnitude difference of the two factors (factor1, factor 2), and then calculates the ratio of the variable rangebetween the measurement point and factor 1, and the range between factor1 and factor 2. By applying this ratio with the predeterminedmathematical function (extrapolation type) to the factors' magnitudedifference and adding it to factor 1 magnitude, results the new factorfor the measured parameter. Other variables can have their owncalibration factors and can be used on measurements at any given pointusing an interpolation algorithm. It is envisioned by this applicationthat the algorithm type, (linear, cube, polynomial, etc.) is selectableto the variable type that best fits the transfer curve. This is based onthe characterization of the measurements needed over the variable range.This technique is not limited to amplitude calibrations and forfrequency but could also apply to temperature, drift, time, phase angleor any other type of movement of the measured parameter.

The calibration of the meter 100 over multiple input ranges isadvantageous, particularly when combined with multiple gain channels asis disclosed herein. As described above, each independently-adjustablegain channel allows the meter to use the associated analog-to-digitalconverter in the most appropriate resolution for the channel's dedicatedtask, while the plurality of ranges over which the meter 100 iscalibrated allows improved accuracy across multiple input ranges. Thus,the combination of features allows the meter 100 to accurately measuresome electrical parameters (e.g., current, voltage, etc.) over a widerange of input values, while still providing sufficiently detailedcapture and/or analysis of other electrical parameters (e.g., waveform,harmonics, etc.).

Although the foregoing text sets forth a detailed description ofnumerous embodiments, it should be understood that the legal scope ofthe present disclosure is defined by the words of the claims set forthat the end of this patent. The detailed description is to be construedas exemplary only and does not describe every possible embodiment, asdescribing every possible embodiment would be impractical, if notimpossible. As a result, one could implement numerous alternateembodiments, using either current technology or technology developedafter the filing date of this patent, which would still fall within thescope of the claims.

It should also be understood that, unless a term is expressly defined inthis patent using the sentence “As used herein, the term ‘______’ ishereby defined to mean . . . ” or a similar sentence, there is no intentto limit the meaning of that term, either expressly or by implication,beyond its plain or ordinary meaning, and such term should not beinterpreted to be limited in scope based on any statement made in anysection of this patent (other than the language of the claims). To theextent that any term recited in the claims at the end of this patent isreferred to in this patent in a manner consistent with a single meaning,that is done for sake of clarity only, so as to not confuse the reader,and it is not intended that such claim term be limited, by implicationor otherwise, to that single meaning. Finally, unless a claim element isdefined by reciting the word “means” and a function without the recitalof any structure, it is not intended that the scope of any claim elementbe interpreted based on the application of 35 U.S.C. §112, sixthparagraph.

Still further, while the figures and description herein are specificallydirected to digital electrical power and energy meters, includingrevenue-quality certified meters, the concepts disclosed in the presentapplication may also be applied in the context of other types ofIntelligent Electronic Devices (IEDs) including, for example,Programmable Logic Controllers (PLCs), Remote Terminal Units (RTUs),protective relays, fault recorders, and other devices or systems used toquantify, manage, and control quality, distribution, and consumption ofelectrical power. Thus, as used herein, the term “digital electricalpower and energy meter” refers broadly to any IED adapted to record,measure, communicate, or act in response to one or more parameters of anelectrical service. These parameters may include, for example, supplycurrents and supply voltages, their waveforms, harmonics, transients,and other disturbances, and other corresponding parameters, such aspower, power quality, energy, revenue, and the like. A variety ofelectrical service environments may employ IEDs and, in particular,digital electrical power and energy meters. By way of example and notlimitation, these environments include power generation facilities(e.g., hydroelectric plants, nuclear power plants, etc.), powerdistribution networks and facilities, industrial process environments(e.g., factories, refineries, etc.), and backup generation facilities(e.g., backup generators for a hospital, a factory, etc.).

Thus, although the disclosure herein has been described with referenceto particular illustrative embodiments, it is to be understood thatthese embodiments are merely illustrative of the principles andapplications of the present disclosure. Therefore, numerousmodifications may be made to the illustrative embodiments and otherarrangements may be devised without departing from the spirit and scopeof the present disclosure.

1. An intelligent electronic device comprising: a sensing circuit havingone or more sensors for sensing at least one parameter of an ACelectrical service, each of the one or more sensors generating a firstsignal representative of the sensed parameter; a plurality ofgain-adjustable channels, each channel having at least one gainadjustment circuit for individually adjusting a gain factor and eachchannel comprising at least one first signal generated by the one ormore sensors, the at least one first signal representative of the sensedparameter, wherein the plurality of gain-adjustable channels include afirst channel for energy calculations, a second channel for harmonicscalculations, and a third channel for waveform capture; one or morecomputer-readable storage devices; and a plurality of calibrationfactors stored in the one or more computer-readable storage devices, theplurality of calibration factors corresponding to a plurality ofcalibration measurements, the plurality of calibration measurementscomprising measurements of a second signal representative of a knownvalue of the parameter at a plurality of signal amplitudes in each of aplurality of calibration ranges.
 2. The device of claim 1, furtherincluding a user interface control which controls the at least one gainadjustment circuit to adjust the gain factor prior to sensing the firstsignal representative of the sensed parameter.
 3. The device of claim 1,further including a gain adjustment routine which controls the at leastone gain adjustment circuit, the gain adjustment routine adjusting thegain factor in response to sensing the first signal representative ofthe sensed parameter.
 4. The device of claim 1, wherein the secondsignal representative of a known value is representative of one of aknown voltage and a known current and wherein the plurality ofcalibration ranges includes 69 V, 120 V, 220 V, and 480 V for secondsignals representative of a known voltage, and 250 mA, 500 mA, 1 A, and5 A for second signals representative of a known current.
 5. The deviceof claim 1, further including a processor that determines at least oneadditional calibration factor using interpolation of the results of theplurality of calibration measurements.
 6. The device of claim 1, furtherincluding a processor that uses interpolation to determine a calibratedmeasurement of a measured data point, the measured data point having avalue between two calibration points.
 7. The device of claim 1, whereinthe plurality of calibration measurements further comprises measurementsof the second signal representative of the known value of the parameterat a plurality of known signal frequencies.
 8. The device of claim 7,wherein the plurality of known signal frequencies includes 50 Hz and 60Hz.
 9. A method for determining at least one parameter of an ACelectrical service using a digital electrical power and energy meter,the method comprising: sensing a plurality of first signals, each of theplurality of first signals comprising a supply voltage or a supplycurrent of the AC electrical service; generating a signal representativeof each of the plurality of first signals; communicating each of theplurality of first signals across each of a plurality of gain-adjustablechannels, each channel having at least one individually-adjustable gainfactor, wherein the plurality of gain-adjustable channels include afirst channel for energy calculations, a second channel for harmonicscalculations, and a third channel for waveform capture; retrieving, fromone or more computer-readable storage devices, one or more calibrationfactors corresponding to one or more of a plurality of calibrationmeasurements, the plurality of calibration measurements comprisingmeasurements of a second signal representative of a known voltage or asignal representative of a known current at a plurality of signalamplitudes in each of a plurality of calibration ranges; and applying aone of the one or more calibration factors to each of the plurality offirst signals to generate a measured value of the first signal, themeasured value of the first signal equal to determine an actual value ofthe parameter.
 10. The method of claim 9, wherein retrieving the one ormore calibration factors further comprises selecting one or more of theindividually-adjustable gain factors prior to sensing the plurality offirst signals.
 11. The method of claim 9, wherein retrieving the one ormore calibration factors further comprises selecting one or more of theindividually-adjustable gain factors in response to sensing theplurality of signals.
 12. The method of claim 9, wherein the pluralityof signal amplitudes includes 69 V, 120 V, 220 V, and 480 V for signalsrepresentative of a known voltage, and 250 mA, 500 mA, 1 A, and 5 A forsignals representative of a known current.
 13. The method of claim 9,further comprising determining at least one additional calibrationfactor using interpolation of the results of the stored calibrationfactors.
 14. The meter of claim 9, further comprising usinginterpolation to determine a calibrated measurement of a measured datapoint, the measured data point having a value between twopreviously-determined calibration points.
 15. The method of claim 9,wherein the plurality of calibration measurements further comprisesmeasurements of the signal representative of the known current or thesignal representative of the known voltage at a plurality of knownsignal frequencies.
 16. The method of claim 13, wherein the plurality ofknown signal frequencies includes 50 Hz and 60 Hz.
 17. A method forcalibrating a digital power and energy meter, the method comprising:providing a plurality of signals in each of a plurality of calibrationranges, each of the plurality of signals comprising one of a knownvoltage signal or a known current signal; taking a measurement, at eachof a plurality of signal amplitudes, of each of the plurality of signalsusing the digital power and energy meter; comparing, for eachmeasurement, the measured value of the known voltage signal or the knowncurrent signal to the actual value of the known voltage signal or theknown current signal; determining, for each measurement, a correspondingcalibration factor; and storing the plurality of calibration factors ina computer-readable storage device, to allow the digital power andenergy meter to apply a corresponding one of the plurality ofcalibration factors in response to a measurement of an unknown voltagesignal or an unknown current signal to determine the value of theunknown voltage signal or the unknown current signal with at least apre-determined level of accuracy; and providing a plurality ofgain-adjustable channels, each channel having at least oneindividually-adjustable gain factor and comprising a plurality ofsignals representative of a sensed voltage or current, wherein theplurality of gain-adjustable channels include a first channel for energycalculations, a second channel for harmonics calculations, and a thirdchannel for waveform capture.
 18. The method of claim 17, wherein theplurality of calibration ranges includes 69 V, 120 V, 220 V, and 480 Vfor signals representative of a known voltage, and 250 mA, 500 mA, 1 A,and 5 A for signals representative of a known current.
 19. The method ofclaim 17, further comprising determining at least one additionalcalibration factor using interpolation of the stored calibrationfactors.
 20. The method of claim 17, further comprising usinginterpolation to determine a calibrated measurement of a measured datapoint, the measured data point having a value between two calibrationpoints.
 21. The method of claim 17, further comprising measuring each ofthe plurality of signal amplitudes at a plurality of signal frequencies.22. The method of claim 21, wherein the plurality of signal frequenciesincludes 50 Hz and 60 Hz.